U.S. patent number 11,274,521 [Application Number 16/985,813] was granted by the patent office on 2022-03-15 for downhole valve and method of use.
This patent grant is currently assigned to COLT PETROLEUM TECHNOLOGY, INC.. The grantee listed for this patent is COLT PETROLEUM TECHNOLOGY, LLC. Invention is credited to Barbara Jan Bailey, Henry Joe Jordan, Jr., Charles David Wintill.
United States Patent |
11,274,521 |
Jordan, Jr. , et
al. |
March 15, 2022 |
Downhole valve and method of use
Abstract
In an embodiment is provided a valve that includes a housing, a
mandrel connected to the housing and defining an interior volume
therebetween, a sleeve having a first end and a second end, the
sleeve movably disposed in the interior volume, a chamber defined
in the interior volume, the chamber having a first end and a second
end, an inlet of a metering device coupled to the second end of the
chamber, and an outlet of the metering device adjacent to the first
end of the sleeve. In another embodiment is provided a method of
using a valve that includes introducing pressure to a central bore
of the valve such that a sleeve of the valve moves from a closed,
locked position to a test position. The closed, locked position and
the test position do not permit fluid communication between a
central bore and an exterior of the valve.
Inventors: |
Jordan, Jr.; Henry Joe (Willis,
TX), Bailey; Barbara Jan (Little Rock, AR), Wintill;
Charles David (Houston, TX) |
Applicant: |
Name |
City |
State |
Country |
Type |
COLT PETROLEUM TECHNOLOGY, LLC |
Little Rock |
AR |
US |
|
|
Assignee: |
COLT PETROLEUM TECHNOLOGY, INC.
(Little Rock, AR)
|
Family
ID: |
1000006174710 |
Appl.
No.: |
16/985,813 |
Filed: |
August 5, 2020 |
Prior Publication Data
|
|
|
|
Document
Identifier |
Publication Date |
|
US 20220042395 A1 |
Feb 10, 2022 |
|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
E21B
34/14 (20130101); E21B 34/063 (20130101); E21B
2200/02 (20200501); E21B 2200/06 (20200501) |
Current International
Class: |
E21B
34/06 (20060101); E21B 34/14 (20060101) |
References Cited
[Referenced By]
U.S. Patent Documents
Primary Examiner: Troutman; Matthew
Assistant Examiner: Lambe; Patrick F
Attorney, Agent or Firm: Patterson + Sheridan, LLP
Claims
What is claimed is:
1. A valve, comprising: a housing; a mandrel connected to the
housing and defining an interior volume therebetween; a sleeve
having a first end and a second end, the sleeve movably disposed in
the interior volume; a channel in fluid communication with the
interior volume; a rupture disc in fluid communication with the
channel, the rupture disc configured to rupture and permit flow of
a wellbore fluid from a central bore of the housing into the
channel; a chamber defined in the interior volume, the chamber
having a first end and a second end; a chamber fluid disposed in
the chamber, the chamber fluid configured to exert a pressure on
the sleeve; a piston in fluid communication with the channel and
the chamber, the piston configured to exert force on the chamber
fluid upon contact of the wellbore fluid with the piston; and a
metering device having: an inlet, the inlet of the metering device
coupled to the second end of the chamber; an outlet, the outlet of
the metering device adjacent to the first end of the sleeve and a
path through which the chamber fluid flows under the force exerted
by the piston, the path of the metering device being defined by
mating first grooves or threads disposed on an outside diameter
face of a metering device inner ring with second grooves or threads
disposed on an inside diameter face of a metering device outer
ring.
2. The valve of claim 1, further comprising a shear screw securing
the sleeve when the valve is in a closed, locked position, the
shear screw configured to shear when the pressure exerted by the
chamber fluid on the sleeve reaches a threshold pressure.
3. The valve of claim 2, wherein the first end of the chamber is
coupled to the piston.
4. The valve of claim 3, wherein: the channel has a first end and a
second end, the piston coupled to the second end of the channel;
and the rupture disc is coupled to the first end of the
channel.
5. The valve of claim 1, further comprising a locking apparatus
configured to secure the sleeve in an open, locked position.
6. The valve of claim 5, wherein the locking apparatus is coupled
to the second end of the sleeve when the sleeve is in an open,
locked position.
7. The valve of claim 1, wherein the sleeve is selectively moveable
between a closed, locked position and an open, unlocked
position.
8. The valve of claim 1, wherein the sleeve is moveable between: a
closed, locked position wherein fluid communication is not
permitted between the central bore and an exterior of the valve; a
test position wherein fluid communication is not permitted between
the central bore and the exterior of the valve; and an open, locked
position wherein fluid communication is permanently permitted
between the central bore and the exterior of the valve.
9. The valve of claim 1, wherein the sleeve has a travel path
between a closed, locked position, an open, locked position, and a
test position between the closed, locked position and the open,
locked position.
10. The valve of claim 9, wherein the sleeve is movable in either
direction between the closed, locked position and the test
position.
11. A valve, comprising: a housing; a mandrel connected to the
housing and defining an interior volume therebetween; a sleeve
having a first end and a second end, the sleeve movably disposed in
the interior volume; a chamber defined in the interior volume, the
chamber having a first end and a second end; a chamber fluid
disposed in the chamber, the chamber fluid configured to exert a
pressure on the sleeve; a piston coupled to the first end of the
chamber, the piston configured to exert force on the chamber fluid
upon contact of a wellbore fluid with the piston; and a metering
device having: an inlet, the inlet of the metering device coupled
to the second end of the chamber; an outlet, the outlet of the
metering device adjacent to the first end of the sleeve, and a path
through which the chamber fluid flows under the force exerted by
the piston, the path of the metering device being defined by mating
first grooves or threads disposed on an outside diameter face of a
metering device inner ring with second grooves or threads disposed
on an inside diameter face of a metering device outer ring.
12. The valve of claim 11, further comprising: a channel having a
first end and a second end, the first end of the channel in fluid
communication with the interior volume, the piston coupled to the
second end of the channel; a rupture disc coupled to the first end
of the channel, the rupture disc configured to rupture and permit
flow of the wellbore fluid from a central bore of the housing and
into the channel; and a locking apparatus configured to secure the
sleeve in an open, locked position.
13. The valve of claim 11, wherein the sleeve is moveable between:
a closed, locked position wherein fluid communication is not
permitted between a central bore of the housing and an exterior of
the valve; a test position wherein fluid communication is not
permitted between the central bore and the exterior of the valve;
and an open, locked position wherein fluid communication is
permanently permitted between the central bore and the exterior of
the valve.
14. The valve of claim 11, wherein: the sleeve has a travel path
between a closed, locked position, an open, locked position, and a
test position between the closed, locked position and the open,
locked position; the sleeve is movable in either direction between
the closed, locked position and the test position; or a combination
thereof.
15. A method of using a valve, comprising: introducing pressure to
a central bore of the valve such that a sleeve of the valve moves
from a closed, locked position to a test position, the valve
comprising: a housing; a mandrel connected to the housing and
defining an interior volume therebetween; the sleeve, the sleeve
having a first end and a second end, the sleeve movably disposed in
the interior volume; a channel in fluid communication with the
interior volume; a rupture disc in fluid communication with the
channel, the rupture disc configured to rupture and permit flow of
a wellbore fluid from the central bore of the housing and into the
channel; a chamber defined in the interior volume, the chamber
having a first end and a second end; a chamber fluid disposed in
the chamber, the chamber fluid configured to exert a hydrostatic
pressure on the sleeve; a piston in fluid communication with the
channel and the chamber, the piston configured to exert force on
the chamber fluid upon contact of the wellbore fluid with the
piston; and a metering device having: an inlet, the inlet of the
metering device coupled to the second end of the chamber; an
outlet, the outlet of the metering device adjacent to the first end
of the sleeve; and a path through which the chamber fluid flows
under the force exerted by the piston, the path of the metering
device is defined by mating first grooves or threads disposed on an
outside diameter face of a metering device inner ring with second
grooves or threads disposed on an inside diameter face of a
metering device outer ring, wherein the closed, locked position
does not permit fluid communication between the central bore and an
exterior of the valve, and wherein the test position does not
permit fluid communication between the central bore and the
exterior of the valve.
16. The method of claim 15, wherein the first end of the chamber is
coupled to the piston.
17. The method of claim 16 wherein: the channel has a first end and
a second end, the piston coupled to the second end of the channel;
and the rupture disc is coupled to the first end of the
channel.
18. The method of claim 15, wherein the sleeve is moveable between:
the closed, locked position; the test position; and an open, locked
position wherein fluid communication is permanently permitted
between the central bore and the exterior of the valve.
19. The method of claim 15, further comprising relieving the
pressure on the central bore of the valve such that the sleeve
moves to the closed, locked position.
20. The method of claim 15, further comprising maintaining the
pressure on the central bore of the valve such that the sleeve
moves to an open, locked position, wherein fluid communication is
permanently permitted between the central bore and the exterior of
the valve.
Description
FIELD
Embodiments of the present disclosure generally relate to drilling
and the related equipment used in, e.g., the oil and gas industry.
More specifically, embodiments of the present disclosure relate to
valves, e.g., downhole valves, and to their methods of use.
BACKGROUND
Valves, such as downhole valves, find applications in at least the
oil and gas industry. The valves are useful for permitting flow of
fluids, e.g., hydrocarbons, between interior portions of the valve
and external portions of the valve. Conventional valves lack the
capability of providing a time period after pressurizing the valve
to examine the valve and other equipment. Typically, after
pressurizing the valve, the valve will lock in an open position
before the valve and other equipment at the rig site can be checked
for desired operability. Once locked, the valve cannot close. If
the equipment is not operating as desired, the operation must be
restarted--including removing the valve from the site by tripping
the pipe and installing a new valve and running the pipe back into
the well.
There is a need for improved valves and methods of use that
overcome one or more deficiencies of conventional valves and
methods of use.
SUMMARY
Embodiments of the present disclosure generally relate to drilling
and the related equipment used in, e.g., the oil and gas industry.
More specifically, embodiments of the present disclosure relate to
valves, e.g., downhole valves, and to their methods of use.
In an embodiment is provided a valve that includes a housing, a
mandrel connected to the housing and defining an interior volume
therebetween, a sleeve having a first end and a second end, the
sleeve movably disposed in the interior volume, a chamber defined
in the interior volume, the chamber having a first end and a second
end, an inlet of a metering device coupled to the second end of the
chamber, and an outlet of the metering device adjacent to the first
end of the sleeve.
In another embodiment is provided a valve that includes a housing,
a mandrel connected to the housing and defining an interior volume
therebetween, a sleeve having a first end and a second end, the
sleeve movably disposed in the interior volume, a chamber defined
in the interior volume, the chamber having a first end and a second
end, a chamber fluid disposed in the chamber, a piston coupled to
the first end of the chamber, the piston configured to exert force
on the chamber fluid, an inlet of a metering device coupled to the
second end of the chamber, and an outlet of the metering device
adjacent to the first end of the sleeve.
In another embodiment is provided a method of using a valve
described herein that includes introducing pressure to a central
bore of the valve such that a sleeve of the valve moves from a
closed, locked position to a test position. The closed, locked
position does not permit fluid communication between a central bore
and an exterior of the valve, and the test position does not permit
fluid communication between the central bore and the exterior of
the valve.
BRIEF DESCRIPTION OF THE DRAWINGS
So that the manner in which the above recited features of the
present disclosure can be understood in detail, a more particular
description of the disclosure, briefly summarized above, may be had
by reference to aspects, some of which are illustrated in the
appended drawings. It is to be noted, however, that the appended
drawings illustrate only exemplary aspects and are therefore not to
be considered limiting of its scope, for the disclosure may admit
to other equally effective aspects.
FIG. 1 is a cross sectional view of an example valve according to
at least one embodiment of the present disclosure.
FIG. 2 is a detailed cross sectional view of a portion of FIG. 1
according to at least one embodiment of the present disclosure.
FIG. 3A is a cross sectional view of an example valve in a closed,
locked position according to at least one embodiment of the present
disclosure.
FIG. 3B is a cross sectional view of an example valve in a closed,
unlocked position according to at least one embodiment of the
present disclosure.
FIG. 3C is a cross sectional view of an example valve in an open,
locked position according to at least one embodiment of the present
disclosure.
To facilitate understanding, identical reference numerals have been
used, where possible, to designate identical elements that are
common to the figures. It is contemplated that elements and
features of one example may be beneficially incorporated in other
examples without further recitation.
DETAILED DESCRIPTION
Embodiments of the present disclosure generally relate to drilling
and related equipment used in, e.g., the oil and gas industry. More
specifically, embodiments of the present disclosure relate to
valves, e.g., downhole valves, and to their methods of use. These
downhole valves can be installed within a casing or a tubing
string. These valves may be used in applications where hydrostatic
pressure can be used to open a valve.
The valves described herein provide flow ports between the internal
and external portions that are selectively isolated until a
successful integrity test of the casing or tubing string is
completed. Hydrostatic pressure applied to the internal portion of
the tool causes movement of an internal piston which pushes a
fluid, e.g., a hydraulic fluid, into a metering device (e.g., a
tortuous path). After exiting the metering device, the fluid then
exerts hydrostatic pressure on a sleeve of the valve until a limit
is reached which permanently opens the valve.
The downhole valves described herein provide a time period between
pressurizing the interior of the casing or tubing string and
setting (or locking) the valve in an open position. For example, a
pressure integrity test can commence by pressurizing the casing or
tubing string. The pressure can be held for a period of time before
the valve opens. During this time period, a user can examine the
valve and other tools at the rig site to ensure that they are
operating as desired. If for any reason the test is desired to be
terminated, the valve may be returned to its original
configuration. In contrast, once conventional casings or tubing
strings are pressurized (e.g., pressurized in the interior diameter
of central bore 122), the valves will lock before the tools can be
checked for desired operability. If the tools are not operating as
desired, the operation must be restarted, including tripping pipe
and re-running pipe back into the well, all of which is very time
consuming. Thus, the valves of the present disclosure can enable
lower costs for drilling.
As discovered by the inventors, the improved valve design described
herein includes a fluid and a metering device through which the
fluid flows. The amount of time where the pressure is held before
the valve opens and locks can be advantageously determined by, at
least, characteristics of the fluid (e.g., viscosity) as well as
the length and/or complexity of the metering device (e.g., a
tortuous path).
Embodiments of the present disclosure generally relate to valves.
FIG. 1 is a cross sectional view of an exemplary valve 100
according to at least one embodiment of the present disclosure. The
exemplary valve 100 includes a housing 105 that defines an outside
diameter of the exemplary valve 100. The exemplary valve 100 also
includes a mandrel 102 that defines an inner diameter of the
passage that goes through it. An interior volume 123 is defined
between the inner diameter of the housing 105 and the outside
diameter of the mandrel 102. A sleeve 118 is slidably disposed in
the interior volume 123 formed between the inner diameter of the
housing 105 and the outside diameter of the mandrel 102. The sleeve
includes seals, e.g., o-rings and back-up rings, on the inside
diameter and outside diameter thereof prevent fluids from moving
across its surface. In some embodiments, sleeve 118 can be made of
a composite material that can advantageously dissolve in the
presence of, e.g., a desired fluid and/or pressure.
The mandrel 102 is trapped between the top sub 101 and the bottom
sub 106. One or more o-rings 114 and one or more back-up rings 111
can be located on the outside diameter of the mandrel 102. The
housing 105 is threadedly coupled to the top sub 101 and to the
bottom sub 106. One or more o-rings 116 and one or more back-up
rings 110 can be located on the inside diameter of the housing 105.
Back-up rings 110, 111 and o-rings 114, 116 serve to prevent
wellbore fluid (or tubing fluid) from entering interior volume 123.
Screws 117, e.g., knurled-cup point set screws, are used to lock
the housing in place once threaded onto the top and bottom subs.
The mandrel 102 defines a central bore 122 for the transmission of
fluids. The central bore 122, as shown in this application,
includes one or more flow ports 121 through which fluids can flow
once the sleeve 118 is moved within the interior volume 123. Both
the mandrel 102 and the housing 105 include ports 124 that allow
selective communication between the central bore 122 and the
exterior of the valve. Flow ports 121 and ports 124 can be
circular, slotted, or of any shape to provide adequate flow
area.
The exemplary valve 100 further includes one or more rupture discs
107. The one or more rupture discs 107 is disposed in a port. The
one or more rupture discs are located in the bottom sub 106 between
the central bore 122 and a channel 127 formed between the bottom
sub 106 and the inner diameter of the housing 105. The channel 127
is in fluid communication with the interior volume 123. The outside
diameter of the bottom sub 106 can be finned, e.g., have a smaller
outside diameter than the threaded portion adjacent to screws 117
to create an annulus. When the rupture disc 107 ruptures, wellbore
fluid (or tubing fluid) from the interior of central bore 122 flows
through the port and into the channel 127.
A piston 104 is slidably disposed in the interior volume 123. The
piston 104 includes seals, e.g., o-rings and back-up rings, on the
inside diameter and outside diameter thereof to prevent fluids from
moving across its surface. During operation, wellbore fluid (or
tubing fluid) can flow from the central bore 122 and into the
channel 127 through the one or more rupture discs 107 once the set
pressure for rupturing the discs has been achieved. In some
embodiments, seals can be placed on the pistons such that the
wellbore fluid (or tubing fluid) does not leak around the piston.
The one or more rupture discs 107 can be application specific,
rupturing at desired pressures based on, e.g., a pressure below the
test pressure. For example, if the pressure on the tube is 20,000
psi, the rupture disc can be selected to rupture at 17,000 psi (or
about 85% of the test pressure).
Piston 104, external ring 113a, and a portion of interior volume
123 create a volume of a chamber 126. A chamber fluid, such as a
hydraulic fluid, e.g., a gear oil, is disposed within the volume of
chamber 126. The chamber fluid does not need to be under pressure.
A viscosity of the chamber fluid is selected to define a time delay
in combination with a metering device defined for the fluid to flow
through. The metering device 125 (e.g., a tortuous path) is defined
by metering device inner ring 103 and metering device outer ring
108. Grooving or threads are disposed on the outside diameter face
of metering device inner ring 103 and in the inside diameter face
of metering device outer ring 108. The grooves or threads when
mated define a metering device 125 through which fluid in interior
volume 123 can flow under pressure created by the piston 104.
FIG. 2 is a detailed cross sectional view showing the metering
device 125 among other components. The metering device 125 (e.g., a
tortuous path) is a restricted pathway through which the chamber
fluid traverses. The metering device 125 can be a threaded path. In
at least one embodiment, a bottom of the metering device 125 can be
defined by metering device outer ring 108 and a top of the metering
device 125 is defined by metering device inner ring 103. External
rings 113a, 113b can be individually disposed both sides of the
metering device inner ring 103 and metering device outer ring 108
to secure the metering device inner ring 103 and metering device
outer ring 108 in place. The external rings 113a, 113b serve to
isolate the metering device 125. The external rings 113a, 113b also
prevent metering device 125 from moving. One or more back-up rings
109 and one or more o-rings 115 can be disposed on the outside
diameter of the mandrel 102 and located between metering device
inner ring 103 and external ring 113b. One or more back-up rings
110 and one or more o-rings 116 can be disposed on the inside
diameter of the housing 105 and located between metering device
inner ring 103 and external ring 113b. Back-up rings 109, 110 and
o-rings 115, 116 serve to prevent the chamber fluid from bypassing
the metering device 125.
Referring again to FIG. 1, a plurality of shear screws 120 can be
located in the housing 105 and can be coupled to sleeve 118 to
secure the sleeve in its initial valve closing position. As a
non-limiting example, the plurality of shear screws 120 can have
tolerances of about 5,000 psi to about 7,000 psi. A support ring
119 can be disposed in a portion of the interior volume. The
support ring 119 can be used to support and maintain the spacing
within the interior volume and minimize the amount of deflection
between components of the tool, e.g., the housing 105 and the
mandrel 102. A locking apparatus, such as one or more lock-snap
rings 112, located in a groove formed in the mandrel 102 and extend
into the interior volume 123. The lock-snap rings 112 lock and/or
friction grip the sleeve 118 when the sleeve moves to the valve
open position.
Embodiments of the present disclosure also relate to methods of
using a valve. Generally, the exemplary valve 100 can include flow
ports 121 and ports 124 between internal and external portions of
the exemplary valve 100. The internal and external portions of the
exemplary valve 100 are selectively isolated until, e.g., an
integrity test of the casing and/or tubing string is completed.
After a successful integrity test is achieved, fluid can transfer
from the interior to the exterior via flow ports 121 and ports 124
once the valve is opened.
FIGS. 3A-3C are cross sectional views of an exemplary valve 100 in
various states of operation according to at least one embodiment of
the present disclosure. The various states of operation can include
a closed, locked position (FIG. 3A), a closed, unlocked position
(FIG. 3B), and an open, locked position (FIG. 3C). The sleeve 118
is slidably movable between at least these positions under fluid
pressure. The sleeve 118 has a travel path between, at least, the
following positions: the closed, locked position; the closed,
unlocked position; and the open, locked position. The sleeve 118
can be slidably movable in either direction between the closed,
locked position, and the closed, unlocked position. The closed,
unlocked position can be referred to as a test position where,
e.g., a test pressure is held for a period of time before the valve
opens and during which the valve and/or other tools can be checked
to ensure desired operability. In some embodiments, and as
non-limiting examples, this period of time can be at least about 30
minutes or more, such as from about 30 minutes to about 120
minutes.
The direction of movement of the sleeve 118 is determined by, at
least, a pressure differential between a first end and second end
of the sleeve 118. The amount of time between the various positions
shown in FIGS. 3A-3C can be regulated by, at least, the dimensions
and characteristics of the metering device and the viscosity of the
chamber fluid. As a non-limiting example, the viscosity of the
chamber fluid can be greater than about 50 cP, such as about 150 cP
or more, such as about 300 cP or more, such as about 380 cP or
more. Selection of the chamber fluid can be based on, at least, its
viscosity.
In use, the exemplary valve 100 can be assembled and the chamber
fluid (e.g., gear oil) can be loaded into the volume of chamber
126. The chamber fluid can be loaded into the volume of chamber 126
off-site or on-site. The exemplary valve 100 can then be run into
the well.
FIG. 3A shows the exemplary valve 100 in a closed, locked position.
At this position, fluid communication is not permitted between the
central bore 122 and an exterior of the exemplary valve 100. That
is, sleeve 118 is positioned to prevent fluid from flowing between
the internal and external portions of the exemplary valve 100. If
it is desired to open the exemplary valve 100, and while the
pressure is still being applied, the rupture disc 107 can rupture
and the wellbore fluid (or tubing fluid) from the interior of the
central bore 122 can enter the channel 127 through the port in
which the rupture disc 107 is disposed. Wellbore fluid (or tubing
fluid) can then exert a force against the piston 104. The piston
104, in turn, can exert force on the chamber fluid located in
chamber 126. The chamber fluid will then enter the metering device
125. The chamber fluid, which can be a high viscosity fluid, can
traverse the metering device 125 and can exit the metering device
125 via metering device inner ring 103. As the pressure builds on
one end of the sleeve 118, the shear screws 120 shear on reaching
the threshold pressure and the sleeve 118 can begin to traverse
away from bottom sub 106 and towards support ring 119.
FIG. 3B shows the valve in a closed, unlocked position where the
chamber fluid has exerted pressure on the sleeve 118 and the shear
screws 120 have sheared. In this closed, unlocked position, the
sleeve 118 remains positioned between the flow ports 121 and ports
124, but the sleeve 118 has traversed away from bottom sub 106 and
towards support ring 119.
FIG. 3C shows the valve in an open, locked position. In the open,
locked position, sleeve 118 has traversed away from the bottom sub
106 and pushed support ring 119 to a position near or coupled to
top sub 101. In addition, the lock-snap ring 112 has locked and/or
friction gripped the sleeve 118, securing the sleeve 118 in the
open, locked position. In the open, locked position, fluid
communication is permitted, e.g., permanently permitted, between
the central bore 122 and an exterior of the exemplary valve 100.
That is, sleeve 118 no longer restricts fluid from flowing between
the internal and external portions of the exemplary valve 100 via
flow ports 121 and ports 124.
To perform a pressure integrity test, the pressure on the interior
of the casing or tubing string can be raised to an identified
target that is typically below that of the valve setting pressure.
This pressure may be held for a period of time before the valve
opens and traverses to the locked position. For example, if the
user loads a test pressure on the tube of 20,000 psi, the rupture
disc can rupture at 17,000 psi (or about 85% of the test pressure).
At this stage, the rupture disc 107 ruptures and the sleeve 118
begins to move. If the sleeve 118 is not fully locked in the open,
locked position, the user can lower the pressure on the interior of
the casing or tubing string if the test is desired to be
terminated, returning the valve to its original configuration of
FIG. 3A. As described above, this pressure can be held for a period
of time to enable the user to check the exemplary valve 100 and
other tools to ensure that the exemplary valve 100 and other tools
are operating as desired. Therefore, testing can be performed
multiple times if desired.
For purposes of this disclosure, and unless otherwise specified,
all numerical values within the detailed description and the claims
herein are modified by "about" or "approximately" the indicated
value, and consider experimental error and variations that would be
expected by a person having ordinary skill in the art.
As used herein, the indefinite article "a" or "an" shall mean "at
least one" unless specified to the contrary or the context clearly
indicates otherwise. For example, embodiments comprising "an
o-ring" include embodiments comprising one, two, or more o-rings,
unless specified to the contrary or the context clearly indicates
only one o-ring is included.
All documents described herein are incorporated by reference
herein, including any priority documents and/or testing procedures
to the extent they are not inconsistent with this text. Further,
all documents and references cited herein, including testing
procedures, publications, patents, journal articles, etc. are
herein fully incorporated by reference for all jurisdictions in
which such incorporation is permitted and to the extent such
disclosure is consistent with the description of the present
disclosure. As is apparent from the foregoing general description
and the specific aspects, while forms of the aspects have been
illustrated and described, various modifications can be made
without departing from the spirit and scope of the present
disclosure. Accordingly, it is not intended that the present
disclosure be limited thereby. Likewise, the term "comprising" is
considered synonymous with the term "including." Likewise whenever
a composition, an element or a group of elements is preceded with
the transitional phrase "comprising," it is understood that we also
contemplate the same composition or group of elements with
transitional phrases "consisting essentially of" "consisting of"
"selected from the group of consisting of" or "Is" preceding the
recitation of the composition, element, or elements and vice versa,
e.g., the terms "comprising," "consisting essentially of,"
"consisting of" also include the product of the combinations of
elements listed after the term.
While the foregoing is directed to embodiments of the present
disclosure, other and further embodiments of the disclosure may be
devised without departing from the basic scope thereof, and the
scope thereof is determined by the claims that follow.
* * * * *